EP1960492B1 - Additive und behandlungsfluide mit chlorierten kohlenhydraten und ihre verwendung - Google Patents

Additive und behandlungsfluide mit chlorierten kohlenhydraten und ihre verwendung Download PDF

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Publication number
EP1960492B1
EP1960492B1 EP06820385A EP06820385A EP1960492B1 EP 1960492 B1 EP1960492 B1 EP 1960492B1 EP 06820385 A EP06820385 A EP 06820385A EP 06820385 A EP06820385 A EP 06820385A EP 1960492 B1 EP1960492 B1 EP 1960492B1
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Prior art keywords
treatment fluid
bwoc
present
cement
cements
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EP06820385A
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English (en)
French (fr)
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EP1960492A1 (de
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William J. Caveny
Rickey L. Morgan
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Halliburton Energy Services Inc
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Halliburton Energy Services Inc
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Priority claimed from US11/291,743 external-priority patent/US7303625B2/en
Priority claimed from US11/291,718 external-priority patent/US7422062B2/en
Priority claimed from US11/291,720 external-priority patent/US7547664B2/en
Application filed by Halliburton Energy Services Inc filed Critical Halliburton Energy Services Inc
Publication of EP1960492A1 publication Critical patent/EP1960492A1/de
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    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B24/00—Use of organic materials as active ingredients for mortars, concrete or artificial stone, e.g. plasticisers
    • C04B24/005—Halogen-containing compounds
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B24/00—Use of organic materials as active ingredients for mortars, concrete or artificial stone, e.g. plasticisers
    • C04B24/10—Carbohydrates or derivatives thereof
    • C—CHEMISTRY; METALLURGY
    • C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
    • C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
    • C04B28/00—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
    • C04B28/02—Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing hydraulic cements other than calcium sulfates
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
    • C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
    • C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes

Definitions

  • the present invention relates to additives for use in treatment operations, and more particularly to additives comprising chlorinated carbohydrates.
  • the invention also relates to treatment fluid compositions, and more particularly to treatment fluid compositions comprising chlorinated hydrocarbons.
  • the invention further relates to subterranean treatment operations, and more particularly, to methods of treating subterranean formations using treatment fluid compositions comprising chlorinated carbohydrates.
  • Hydraulic cement compositions commonly are utilized in subterranean operations, particularly subterranean well completion and remedial operations.
  • hydraulic cement compositions are used in primary cementing operations whereby pipe strings such as casings and liners are cemented in well bores.
  • primary cementing hydraulic cement compositions are pumped into the annular space between the walls of a well bore and the exterior surface of a pipe string disposed therein.
  • the cement composition is permitted to set in the annular space, thereby forming therein an annular sheath of hardened substantially impermeable cement that substantially supports and positions the pipe string in the well bore and bonds the exterior surface of the pipe string to the walls of the well bore.
  • Hydraulic cement compositions also are used in remedial cementing operations such as plugging highly permeable zones or fractures in well bores, plugging cracks and holes in pipe strings, and the like.
  • Set retarders commonly may be included in cement compositions, among other things, to delay the set time of the cement composition.
  • set retarders may delay the set time of a cement composition exposed to high subterranean temperatures, and thereby extend the time during which the cement composition may remain pumpable after the cement composition has been mixed.
  • a variety of conventional set retarders have been developed and used successfully, including, inter alia, sugars, borates, phosphate compounds, and lignin-based compounds.
  • the use of conventional set retarders may be problematic.
  • conventional set retarders undesirably may slow the development of a cement's compressive strength.
  • conventional set retarders may be incompatible with certain cement additives, and conventional set retarders may not be suitable for use in environmentally sensitive applications.
  • the present invention relates to additives for use in treatment operations, and more particularly, to additives comprising chlorinated carbohydrates.
  • the invention also relates to treatment fluids for use in treatment operations, particularly treatment fluids comprising chlorinated hydrocarbons.
  • the invention further relates to treatment operations using chlorinated hydrocarbons.
  • a treatment fluid comprising: a hydraulic cement; water and a set retarding additive according to the present invention.
  • a method of treating a subterranean formation comprising: providing a treatment fluid comprising water, a hydraulic cement, and a chlorinated carbohydrate; placing the treatment fluid in a subterranean formation; and permitting the treatment fluid to treat the formation.
  • Figure 1 illustrates the results of a crush test on sample compositions, including a cement composition of the present invention.
  • the present invention relates to additives for use in treatment operations, and more particularly, to additives comprising chlorinated carbohydrates.
  • the invention also relates to treatment fluid compositions comprising chorinated hydrocarbons. While the compositions and methods of the present invention are useful in a variety of applications, they may be particularly useful for subterranean well completion and remedial operations, such as primary cementing of casings and liners in well bores, including those in production wells, which include multi-lateral subterranean wells. They also may be useful for surface cementing operations, including construction cementing operations.
  • the treatment fluid compositions of the present invention generally comprise a cement, water, and a chlorinated carbohydrate.
  • the presence of a chlorinated carbohydrate in the treatment fluid compositions of the present invention desirably may retard the setting time of the treatment fluid compositions, without delaying compressive strength development.
  • the chlorinated carbohydrate desirably may retard the setting time of the treatment fluid compositions of the present invention while accelerating early compressive strength development.
  • the treatment fluid compositions of the present invention comprising a chlorinated carbohydrate ultimately may develop compressive strength that exceeds the compressive strength that the treatment fluid compositions of the present invention ultimately would develop without the presence of the chlorinated carbohydrate.
  • Certain embodiments of the treatment fluid compositions of the present invention may have environmental benefits, particularly when used in regions of the world that may have comparatively strict environmental regulations.
  • the treatment fluid compositions of the present invention comprise a hydraulic cement.
  • hydraulic cements are suitable for use, such as those comprising one or more of calcium, aluminum, silicon, oxygen, and sulfur, which set and harden by reaction with water.
  • hydraulic cements include, but are not limited to, Portland cements, pozzolanic cements, gypsum cements, high alumina content cements, silica cements, high alkalinity cements, slag cements, shale cements, and mixtures thereof.
  • a hydraulic cement may be used that comprises a mixture of Portland cement and slag.
  • a hydraulic cement may be used that comprises slag activated with a suitable alkali activator (e.g., soda ash and/or caustic).
  • the hydraulic cement comprises a vitrified shale.
  • An example of a suitable vitrified shale is commercially available under the trade name "PRESSURE-SEAL ® FINE LCM" vitrified shale from TXI Energy Services, Inc., Houston, Texas.
  • the hydraulic cement comprises an API cement, such as API Classes A, B, C, G, H, or J Portland cements, or equivalents thereof.
  • API cements are defined and described in API Specification for Materials and Testing for Well Cements, API Specification 10A, 22nd Edition, dated Jan. 1, 1995 .
  • the water utilized in the treatment fluid compositions of the present invention may be fresh water, saltwater (e.g., water containing one or more salts dissolved therein), brine (e.g., saturated saltwater), or seawater.
  • the water may be from any source provided that it does not contain an excess of compounds that adversely affect the treatment fluid compositions.
  • the water may be present in an amount sufficient to form a pumpable slurry.
  • the water is present in the treatment fluid compositions of the present invention in an amount in the range of from about 15% to about 200% by weight of cement ("bwoc") therein.
  • the water may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 25% to about 60% bwoc therein.
  • chlorinated carbohydrates may be used in the treatment fluid compositions of the present invention.
  • chlorinated carbohydrate will be understood to include any carbohydrate that comprises one or more chlorine atoms.
  • the term specifically includes, inter alia, sucralose and derivatives thereof, as well as 4-chloro-4-deoxygalactose (sometimes referred to as "4-CG”) and 1,6-dichloro-1,6-dideoxyfructose (sometimes referred to as "1,6-DCF").
  • the term “derivative” will be understood to include any compound that is made from one of the listed compounds (e.g., made from sucralose), for example, by replacing one atom in the listed compound with another atom or group of atoms.
  • sucralose will be understood to include a chlorinated carbohydrate having the chemical name 1,6-dichloro-1,6-dideoxy- ⁇ -D-fructofuranosyl-4-chloro-4-deoxy- ⁇ -D-galactopyranoside that has been assigned CAS Number 56-038-13-2.
  • Sucralose often may be referred to (in technical literature, material safety data sheets, marketing materials, and the like) by a number of synonyms, including, for example and without limitation: "1,6-dichloro-1,6-dideoxy- ⁇ -D-fructofuranosyl-4-chloro-4-deoxy- ⁇ -D-galactose”; “trichlorogalactosucrose”; “TGS”; “4,1',6'-trichlorogalactosucrose”; and "SPLENDA”.
  • the chlorinated carbohydrates may comprise sucralose.
  • a suitable source of sucralose is commercially available under the trade name "SPLENDA.”
  • the chlorinated carbohydrates may comprise one or more of 4-chloro-4-deoxygalactose, 1,6-dichloro-1,6-dideoxyfructose, and derivatives thereof.
  • the chlorinated carbohydrates should be present in the treatment fluid compositions of the present invention in an amount sufficient to retard the setting of the treatment fluid compositions of the present invention for a desired time.
  • the amount of chlorinated carbohydrates that may be included may depend on a number of factors, including, but not limited to, the bottom hole circulating temperature of the well into which the treatment fluid is to be placed, the particular formulation of the chosen chlorinated carbohydrates, and the like.
  • the quantity of the chlorinated carbohydrates to be included in the treatment fluid composition may be determined prior to preparation of the treatment fluid composition For example, the quantity of the chlorinated carbohydrates to be included in the treatment fluid composition may be determined by performing thickening time tests of the type described in API Specification 10A, Twenty-Third Edition, April, 2002 .
  • the chlorinated carbohydrates may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 0.01% to about 5% bwoc. In some embodiments, the chlorinated carbohydrates may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 0.1% to about 1% bwoc.
  • the treatment fluid compositions of the present invention may comprise a dispersant.
  • the dispersant may control the rheology of the treatment fluid composition and stabilize the treatment fluid composition over a broad density range.
  • a variety of dispersants known to those skilled in the art may be used in accordance with the present invention.
  • An example of a suitable dispersant is a watersoluble polymer prepared by the caustic-catalyzed condensation of formaldehyde with acetone wherein the polymer contains sodium sulfate groups, which dispersant is commercially available under the trade designation "CFR-3TM" dispersant from Halliburton Energy Services, Inc., Duncan, Oklahoma.
  • CFR-2TM Commercially available under the trade designation "CFR-2TM” dispersant, also from Halliburton Energy Services, Inc., of Duncan, Oklahoma.
  • the dispersant may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 0.1 % to about 2.0 % bwoc. In some embodiments, the dispersant may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 0.1 % to about 1.0 % bwoc.
  • the treatment fluid compositions of the present invention may comprise a hydratable polymer.
  • the hydratable polymer may increase the viscosity of the treatment fluid compositions of the present invention, among other things.
  • Various hydratable polymers can be utilized in the treatment fluid compositions of the present invention including, but not limited to; carboxymethylcellulose, hydroxyethylcellulose, carboxymethylhydroxyethylcellulose, vinyl sulfonated polymers, and hydratable graft polymers.
  • a suitable hydratable polymer is a cellulose derivative commercially available from Dow Chemical Co., under the trade name "CARBOTRON 20.”
  • the hydratable polymer may be present in the treatment fluid compositions of the present invention in an amount sufficient to contribute a desired degree of viscosity to the treatment fluid compositions of the present invention.
  • the hydratable polymer may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 0.01 % to about 5.0 % bwoc.
  • the hydratable polymer may be present in the treatment fluid compositions of the present invention in an amount in the range of from about 0.1 % to about 2.0 % bwoc.
  • the additives of the present invention generally comprise a chlorinated carbohydrate.
  • a chlorinated carbohydrate may be combined with a tartaric acid to form another additive of the present invention.
  • the additives of the present invention that comprise a chlorinated carbohydrate and a tartaric acid may comprise about 60% to about 90% chlorinated carbohydrate by weight, and about 10% to about 40% tartaric acid by weight.
  • the additives of the present invention that comprise a chlorinated carbohydrate and a tartaric acid may comprise about 70% to about 80% chlorinated carbohydrate by weight, and about 20% to about 30% tartaric acid by weight.
  • the additives of the present invention that comprise a chlorinated carbohydrate and a tartaric acid may comprise tartaric acid in an amount in the range of from about 10% to about 70% by weight of the chlorinated carbohydrate. In certain embodiments of the present invention the additives of the present invention that comprise a chlorinated carbohydrate and a tartaric acid may comprise tartaric acid in an amount in the range of from about 25% to about 45% by weight of the chlorinated carbohydrate.
  • the additives of the present invention comprising chlorinated carbohydrates may retard the setting of the treatment fluid compositions of the present invention at a variety of temperatures, including temperatures of up to about 200 °F (93°C) in certain embodiments, temperatures of up to about 250 °F (121°C) in certain embodiments, and temperatures greater than about 250 °F (121°C) in certain embodiments.
  • the treatment fluid compositions of the present invention comprising chlorinated carbohydrates may be suitable for use at a variety of temperatures. Certain embodiments of the treatment fluid compositions of the present invention are suitable for use at temperatures of up to about 200 °F (93°C). Certain embodiments of the treatment fluid compositions of the present invention are suitable for use at temperatures of up to about 250 °F (121°C). Certain embodiments of the treatment fluid compositions of the present invention may be suitable for use at temperatures greater than about 250 °F (121°C). In some embodiments, additives may be included in the treatment fluid compositions of the present invention to facilitate use at elevated temperatures.
  • the treatment fluid compositions of this invention also may include additional suitable additives, including, among other things, accelerants, defoamers, silica, microspheres, viscosifiers, fibers, weighting materials, salts, vitrified shale, calcium hydroxide, fly ash, fluid loss control additives, set retarders and the like.
  • Any suitable additive may be incorporated within the treatment fluid compositions of the present invention.
  • An example of a suitable silica is a fine silica flour that is commercially available from Halliburton Energy Services, Inc., of Duncan, Oklahoma, under the trade name "SSA-1TM" fine silica flour.
  • a suitable fluid loss control additive is commercially available from Halliburton Energy Services, Inc., of Duncan, Oklahoma, under the trade name "FWCA” additive.
  • An example of a suitable high-temperature viscosifier is commercially available from Halliburton Energy Services, Inc., of Duncan, Oklahoma, under the trade name "SUSPEND HT” anti-settling additive.
  • suitable set retarders include various organic acids including, but not limited to, tartaric acid, citric acid, gluconic acid, oleic acid, phosphoric acid, and uric acid.
  • An example of a suitable tartaric acid is commercially available from Halliburton Energy Services, Inc., of Duncan, Oklahoma, under the trade name "HR ® -25" retarder.
  • Sample treatment fluid compositions were prepared as follows. A cementitious material (Texas Lehigh Class H) and chlorinated carbohydrate were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously. Next, a slurry was formed by adding an amount of water in a one-liter Waring blender, and then adding the dry-blended materials while the blender operated at about 2,500 rpm. Once all dry-blended materials had been added, the mixture in the blender was sheared at about 13,000 rpm for 35 seconds. Next, tests were run to determine the pump time of the sample composition at high temperature and high pressure according to API RP 10B, "Recommended Practices for Testing Oil-Well Cements and Cement Additives," dated 1974 . The sample composition also was tested using an ultrasonic cement analyzer to determine its strength at a desired temperature and pressure.
  • Sample Composition No. 1 comprised Texas Lehigh Class H cement and 39.4% water bwoc, with no chlorinated carbohydrate.
  • Sample Composition No. 2 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.25% sucralose bwoc and 39.4% water bwoc.
  • Sample Composition No. 3 comprised Texas Lehigh Class H cement and 39.4% water bwoc, with no chlorinated carbohydrate.
  • Sample Composition No. 4 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.1% sucralose bwoc and 39.4% water bwoc.
  • the caption "500 Psi (3.45MPa) Time” refers to the time required for the sample composition to develop 500 psi (3.45MPa) compressive strength.
  • the captions "24 Hr. Strength (psi)” and “48 Hr. Strength (psi)” refer to the strength (measured in psi) that the sample composition had attained by 24 hours, and 48 hours, respectively, after the onset of testing.
  • the caption “48 Hr. Crush Strength (psi)” refers to the strength (measured in psi) required to crush the sample composition at a time 48 hours after the onset of testing.
  • Example 1 illustrates, inter alia, that the treatment fluid compositions of the present invention comprising chlorinated carbohydrates are suitable for use in subterranean and surface cementing operations.
  • Sample treatment fluid compositions were prepared as follows. A cementitious material (Texas Lehigh Class H) and chlorinated carbohydrate were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously. In some sample treatment fluid compositions, as indicated below, one or more of the following additives were also dry blended with the sample treatment fluid compositions: B-8 (octaborate), SSA-1TM fine silica flour, FWCA additive, and SUSPEND HT anti-settling additive. Next, a slurry was formed by adding an amount of water in a one-liter Waring blender, and then adding the dry-blended materials while the blender operated at about 2,500 rpm.
  • a cementitious material Texas Lehigh Class H
  • chlorinated carbohydrate were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously.
  • one or more of the following additives were also dry blended with the sample treatment fluid compositions: B-8 (octaborate), SSA-1TM fine silica flour, FW
  • Sample Composition No. 5 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 2% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 6 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1.5% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 7 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 8 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.5% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, and 48.55% water bwoc.
  • Sample Composition No. 9 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, 0.05% FWCA additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 10 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1.5% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, 0.05% FWCA additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 11 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.75% sucralose bwoc, 35% SSA-1TM fine silica flour bwoc, 0.05% FWCA additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 12 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.5% sucralose bwoc, 0.5% B-8 bwoc, 35% SSA-1TM fine silica flour bwoc, 0.05% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 13 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.5% sucralose bwoc, 1% B-8 bwoc, 35% SSA-1TM fine silica flour bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.55% water bwoc.
  • Sample Composition No. 7 also was tested using an ultrasonic cement analyzer to determine its strength at a desired temperature and pressure, the results of which are shown in Table 4 below.
  • Table 4 Sample Composition Water (% bwoc) Sucralose (% bwoc) Test Temp. (°F) 500 Psi (3.45MPa) Time (hr:min) 24 Hr. Strength (psi) 48 Hr. Strength (psi) No. 7 48.55 1 300 12:31 3,369 (23.2MPa) 3,540 (24.4MPa)
  • Example 2 illustrates, inter alia, that the treatment fluid compositions of the present invention comprising chlorinated carbohydrates are suitable for use in subterranean and surface cementing operations.
  • Sample treatment fluid compositions were prepared as follows. A cementitious material (Texas Lehigh Class H), a chlorinated carbohydrate, and B-8 (octaborate) were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously. Next, a slurry was formed by adding an amount of water in a one-liter Waring blender, and then adding the dry-blended materials while the blender operated at about 2,500 rpm. Once all dry-blended materials had been added, the mixture in the blender was sheared at about 13,000 rpm for 35 seconds.
  • a cementitious material Texas Lehigh Class H
  • a chlorinated carbohydrate a chlorinated carbohydrate
  • B-8 octaborate
  • Sample Composition No. 14 comprised Texas Lehigh Class H cement, 0.1% B-8 bwoc, and 39.4% water bwoc.
  • Sample Composition No. 15 comprised Texas Lehigh Class H cement, 0.2% B-8 bwoc, and 39.4% water bwoc.
  • Sample Composition No. 16 comprised Texas Lehigh Class H cement, 0.3% B-8 bwoc, and 39.4% water bwoc.
  • Sample Composition No. 17 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.05% sucralose bwoc, 0.1% B-8 bwoc, and 39.4% water bwoc.
  • Sample Composition No. 18 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 0.1% sucralose bwoc, 0.1% B-8 bwoc, and 39.4% water bwoc.
  • Example 3 illustrates, inter alia, that the treatment fluid compositions of the present invention comprising chlorinated carbohydrates are suitable for use in subterranean and surface cementing operations.
  • Sample compositions were prepared as follows. A cementitious material (Texas Lehigh Class H) and chlorinated carbohydrate were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously. In some sample compositions, as indicated below, one or more of the following additives were also dry blended with the sample compositions: B-8 (octaborate), HR ® -25 retarder, SSA-1TM fine silica flour, FWCA additive, and SUSPEND HT anti-settling additive. Next, a slurry was formed by adding an amount of water in a one-liter Waring blender, and then adding the dry-blended materials while the blender operated at about 2,500 rpm.
  • a cementitious material Texas Lehigh Class H
  • chlorinated carbohydrate were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously.
  • one or more of the following additives were also dry blended with the sample compositions: B-8 (octaborate), HR ® -25 retarder, SSA-1TM
  • Sample Composition No. 19 comprised Texas Lehigh Class H cement, 1% B-8 bwoc, 35% SSA-1TM fine silica flour bwoc, and 48.55% water bwoc.
  • Sample Composition No. 20 comprised Texas Lehigh Class H cement, 0.25% B-8 bwoc, and 39.4% water bwoc.
  • Sample Composition No. 21 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1% sucralose bwoc, 0.25% HR ® -25 retarder bwoc, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.42% water bwoc.
  • Sample Composition No. 22 comprised Texas Lehigh Class H cement, 0.25% HR ® -25 retarder bwoc, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.42% water bwoc.
  • Sample Composition Nos. 21 and 22 also were tested using an ultrasonic cement analyzer to determine their strength at a desired temperature and pressure, the results of which are shown in Table 7 below.
  • TABLE 7 Sample Composition Water (% bwoc) Sucralose (% bwoc) Test Temp. (°F) 500 Psi (3.45MPa) Time (hr:min) 24 Hr. Strength (psi) 48 Hr. Strength (psi) No. 21 48.42 1 300 (149°C) 7:34 5,544 (38.2MPa) 5,800 (at 46 Hr.) (40.0MPa) No. 22 48.42 0 300 (149°C) 6:24 4,397 (30.3MPa) 4,479 (30.8MPa)
  • Example 4 illustrates, inter alia, that the treatment fluid compositions of the present invention comprising chlorinated carbohydrates are suitable for use in subterranean and surface cementing operations.
  • Sample compositions were prepared as follows. A cementitious material (Texas Lehigh Class H) and an additive of the present invention comprising sucralose and HR ® -25 retarder were dry blended by adding dry materials in a one-liter glass jar and shaking vigorously.
  • the additive of the present invention comprising sucralose and HR ® -25 retarder comprised a blend of 1 part HR ® -25 retarder and 4 parts sucralose.
  • one or more of the following additives were also dry blended with the sample compositions: SSA-1TM fine silica flour, FWCA additive, and SUSPEND HT anti-settling additive.
  • a slurry was formed by adding an amount of water in a one-liter Waring blender, and then adding the dry-blended materials while the blender operated at about 2,500 rpm. Once all dry-blended materials had been added, the mixture in the blender was sheared at about 13,000 rpm for 35 seconds. Next, tests were run to determine the pump time of the sample composition at high temperature and high pressure according to API RP 10B, "Recommended Practices for Testing Oil-Well Cements and Cement Additives," dated 1974.
  • Sample Composition No. 23 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1% additive of the present invention comprising sucralose and HR ® -25 retarder, 35% SSA-1TM fine silica flour bwoc, 0.05% FWCA additive bwoc, and 48.5% water bwoc.
  • Sample Composition No. 24 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 1.25% additive of the present invention comprising sucralose and HR ® -25 retarder, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.2% SUSPEND HT anti-settling additive bwoc, and 48.42% water bwoc.
  • Sample Composition No. 25 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 2% additive of the present invention comprising sucralose and HR ® -25 retarder, 35% SSA-1TM fine silica flour bwoc, 0.15% FWCA additive bwoc, 0.3% SUSPEND HT anti-settling additive bwoc, and 48.4% water bwoc.
  • Sample Composition No. 26 a treatment fluid composition of the present invention, comprised Texas Lehigh Class H cement, 3% additive of the present invention comprising sucralose and HR ® -25 retarder, 35% SSA-1TM fine silica flour bwoc, 0.1% FWCA additive bwoc, 0.25% SUSPEND HT anti-settling additive bwoc, and 48.44% water bwoc.
  • Example 5 illustrates, inter alia, that the treatment fluid compositions of the present invention comprising the additives of the present invention are suitable for use in subterranean and surface cementing operations.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Ceramic Engineering (AREA)
  • Materials Engineering (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Organic Chemistry (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Structural Engineering (AREA)
  • Inorganic Chemistry (AREA)
  • Molecular Biology (AREA)
  • Health & Medical Sciences (AREA)
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  • Curing Cements, Concrete, And Artificial Stone (AREA)
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Claims (13)

  1. Behandlungsfluid, Folgendes umfassend: hydraulischen Zement, Wasser und ein chloriertes Kohlenhydrat, wobei das chlorierte Kohlenhydrat Sucralose oder ein Derivat davon, 4-Clor-4-deoxygalactose oder ein Derivat davon oder 1,6-Dichloro-1,6-dideoxyfructose oder ein Derivat davon umfasst.
  2. Behandlungsfluid nach Anspruch 1, ferner Weinsäure umfassend.
  3. Behandlungsfluid nach Anspruch 2, wobei die Weinsäure in einer Menge im Bereich von 10 bis 70 Gew.-% des chlorierten Kohlenhydrats vorhanden ist.
  4. Behandlungsfluid nach Anspruch 1 oder 2, wobei das Behandlungsfluid eine Zementzusammensetzung ist.
  5. Behandlungsfluid nach Anspruch 4, wobei das chlorierte Kohlenhydrat in der Zementzusammensetzung in einer Menge im Bereich von 0,01 bis 5 Gew.-% des hydraulischen Zements vorhanden ist.
  6. Behandlungsfluid nach Anspruch 4 oder 5, wobei das chlorierte Kohlenhydrat in der Zementzusammensetzung in einer Menge im Bereich von 0,1 bis 1 Gew.-% des hydraulischen Zements vorhanden ist.
  7. Behandlungsfluid nach einem der vorhergehenden Ansprüche, wobei der hydraulische Zement einen Zement umfasst, der aus der folgenden Gruppe ausgewählt ist: Portlandzementen, Puzzolanzementen, Gipszementen, Zementen mit hohem Aluminiumoxidgehalt, Silikazementen, Zementen mit hoher Alkalität, Schlackezementen, verglastem Schiefer oder Kombinationen daraus.
  8. Behandlungsfluid nach einem der vorhergehenden Ansprüche, wobei das Wasser in der Zementzusammensetzung in einer Menge im Bereich von 15 bis 200 Gew.-% des hydraulischen Zements vorhanden ist.
  9. Behandlungsfluid nach einem der vorhergehenden Ansprüche, ferner Folgendes umfassend: ein Additiv, das aus der folgenden Gruppe ausgewählt ist: einem Dispersionsmittel, einem hydratisierbaren Polymer und einem Verzögerer.
  10. Verfahren zur Behandlung einer unterirdischen Formation, Folgendes umfassend: Anordnen des Behandlungsfluids nach einem der Ansprüche 1 bis 5 oder 7 in einer unterirdischen Formation und Ermöglichen der Behandlung der Formation durch das Behandlungsfluid.
  11. Verfahren nach Anspruch 10, ferner das Ermöglichen umfassend, dass das chlorierte Kohlenhydrat das Abbinden des Behandlungsfluids verzögert.
  12. Verfahren nach Anspruch 10, wobei das Anordnen des Behandlungsfluids in einer unterirdischen Formation das Anordnen des Behandlungsfluids in einem Bereich einer unterirdischen Formation umfasst, der eine Temperatur von mehr als 200 °F (93 °C) aufweist.
  13. Verfahren nach Anspruch 10, wobei das Behandlungsfluid eine Zementzusammensetzung ist und wobei das Ermöglichen der Behandlung der Formation durch das Behandlungsfluid das Ermöglichen umfasst, dass die Zementzusammensetzung in der Formation abbindet, um eine Zementhülle zu bilden.
EP06820385A 2005-12-01 2006-11-30 Additive und behandlungsfluide mit chlorierten kohlenhydraten und ihre verwendung Not-in-force EP1960492B1 (de)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US11/291,743 US7303625B2 (en) 2005-12-01 2005-12-01 Treatment fluids comprising chlorinated carbohydrates
US11/291,718 US7422062B2 (en) 2005-12-01 2005-12-01 Methods of treating subterranean formations using treatment fluids comprising chlorinated carbohydrates
US11/291,720 US7547664B2 (en) 2005-12-01 2005-12-01 Additives comprising chlorinated carbohydrates
PCT/GB2006/004486 WO2007063319A1 (en) 2005-12-01 2006-11-30 Additives and treatment fluids comprising chlorinated carbohydrates and methods of using them

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EP1960492A1 EP1960492A1 (de) 2008-08-27
EP1960492B1 true EP1960492B1 (de) 2013-02-27

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US7547664B2 (en) 2005-12-01 2009-06-16 Halliburton Energy Services, Inc. Additives comprising chlorinated carbohydrates
CN102827592A (zh) * 2012-09-03 2012-12-19 中国海洋石油总公司 一种耐高温稠化时间长的水泥浆

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US5220960A (en) * 1992-02-19 1993-06-22 Halliburton Company Retarded acid soluble well cement compositions and methods
WO2002041705A2 (en) * 2000-11-17 2002-05-30 Mcneil-Ppc, Inc. Meltable form of sucralose
WO2004076376A2 (en) * 2003-02-26 2004-09-10 Construction Research & Technology Gmbh Strength improvement admixture
DE10348723A1 (de) * 2003-10-16 2005-05-12 Nutrinova Gmbh Süßstoffkombination zur Süßung von Obstkonserven

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DK1960492T3 (da) 2013-05-27
NO20082851L (no) 2008-08-27
WO2007063319A1 (en) 2007-06-07

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